Pressure and mechanically operated valve



Sept. 16, 1969 5, DQWDEN PRESSURE AND MECHANICALLY OPERATED VALVE 3Sheets-Sheet 1 Filed May 22. 1967 w mn H V 2mm W w R 3m! .m m F5 Sept.16, 1969 s. R. DOWDEN PRESSURE AND MECHANICALLY OPERATED VALVE 3Sheets-Sheet 2 Filed May 22, 1967 R w 0 A m. m W n m e w 2 m A .m o F DR. //W X 0 M r O f n A 2 s W Q 3 Q m C! 8 m b. F H -ELI-EZI E: L52: .2.MU M Sept. 16, 1969 s. R. DOWDEN PRESSURE AND MECHANICALLY OPERATEDVALVE 3 Sheets-Sheet 3 Filed May 22, 1967 6 m M 2 1Q I H g n Wm F W w mN x O 1 m o y 4, 7 f4 m. 0 v Q a w 5 w .u. '11 S M 1 1 6 I 3"lllliin'l rY K/ z B m. J M

... lnll ll United States Patent Ofiice 3,467,185 Patented Sept. 16,1969 3,467,185 PRESSURE AND MECHANICALLY OPERATED VALVE Sanford R.Dowden, Morgan City, La., assignor to Otis Engineering Corporation,Dallas, Tex., a corporation of Delaware Filed May 22, 1967, Ser. No.640,249 Int. Cl. E21b 33/12; F16k 31/12 U.S. Cl. 166-147 23 ClaimsABSTRACT OF THE DISCLOSURE An apparatus for circulating fluid through awell bore preparatory to the setting of a well packer within the wellbore including a sliding sleeve valve for controlling flow through alateral port in a flow conductor between a pair of packers. The sleevevalve is opened by fluid pressure within the flow conductor afterplugging the conductor below the valve and is closed by mechanical forceapplied by a second flow conductor adapted to move relative to the firstconductor.

This invention relates to well tools and more particularly relates tocirculation devices for use in well bores.

It is an object of the invention to provide a well tool for circulatingfluid between the interior and exterior of a flow conductor.

It is another object of the invention to provide a sliding sleeve valvefor controlling fluid communication between the interior and exterior ofa flow conductor disposed in a well bore.

It is another object of the invention to provide a sliding sleeve valvefor a flow conductor which is opened by a fluid pressure differentialbetween the interior and exterior of the flow conductor and is closed bya mechanical force.

It is another object of the invention to provide a sleeve valve for useon a flow conductor between packers in a well bore for circulatingbetween the well bore and the flow conductor, the sleeve valve beingoperable by a fluid pressure differential between the interior andexterior of the flow conductor for opening the valve and being movableto a closed position by a mechanical force transmitted to the valve froma second flow conductor in the well bore movable relative to the firstflow conductor.

It is still another object of the invention to provide a circulatingdevice for a flow conductor which includes a sleeve valve slidablysupported on the flow conductor for movement between positions coveringand uncovering the lateral port in the conductor and having inner andouter seal means for sealing between the portions of the sleeve valveand the flow conductor and defining an annular area of the sleeve valveexposed on one side to pressure within the flow conductor and on theother side to pressure exterior of the flow conductor, the sleeve valvebeing movable to an open position by a pressure within the flowconductor greater than the pressure exterior of the flow conductor, andincluding an operator member slidable on the flow conductor for engagingthe sleeve valve to move the valve from an open position back to aclosed position over the port.

It is still another object of the invention to provide a sleeve valvefor a flow conductor to control communication between the interior andexterior of the flow conductor through a lateral port in the conductor,the sleeve valve including first and second sleeve valve memberstelescopicably related and slidable on the flow conductor, the firstsleeve valve member initially closing the port and being movable on theflow conductor by a fluid pressure differential between the interior andexterior of the flow conductor to open the port and the second sleevevalve member being movable toward the port and the first sleeve valvemember to close the port by application of a mechanical force thereto.

It is another object of the invention to provide in combination with asliding sleeve valve on a long flow conductor a lower packer on the flowconductor below the sliding sleeve valve' and an upper packer around thelong flow conductor and a short flow conductor above the sliding sleevevalve, the upper packer permitting the short flow conductor to movedownwardly relative to the long flow conductor for returning the slidingsleeve valve to its closed position.

Additional objects and advantages of the invention will be readilyapparent from the reading of the following description of a deviceconstructed in accordance with the invention, and reference to theaccompanying drawings thereof, wherein:

FIGURE 1 is a schematic longitudinal view in section and elevation of awell system including one form of circulating device embodying theinvention shown at its first closed position before the upper packer isset;

FIGURE 2 is a view similar to FIGURE 1 showing the lower packer expandedwithin the well bore and the circulating device in its open position;

FIGURE 3 is a view similar to FIGURE 2 showing the circulating devicemoved to a closed position and the upper packer expanded;

FIGURE 2A is a longitudinal diagrammatic view in section and elevationof one form of upper packer used with the circulating device showing theupper packer as it is run into the well bore and before the closing ofthe circulating device;

FIGURE 3A is a view similar to FIGURE 2A showing the upper packerexpanded;

FIGURE 4 is an enlarged fragmentary longitudinal view in section andelevation of the circulating device illustrated in FIGURES l-3, showingthe device at its first closed position while running into the wellbore;

FIGURE 5 is a further enlarged fragmentary view in section and elevationof only a lower portion of the sleeve valve of the circulating device ofFIGURE 4;

FIGURE 6 is a view in section along the line 6-6 of FIGURE 4;

FIGURE 7 is a fragmentary longitudinal view in section and elevation ofan alternate form of circulating device embodying the invention, showingits sleeve valve closed; and,

FIGURE 8 is a longitudinal schematic view in section and elevationsimilar to FIGURES 1-3 of an alternate form of the circulating device ofFIGURE 7.

Referring to the drawings, particularly FIGURE 1, a circulating device20 embodying the invention is supported on a section 21' of a longtubing string 21 and a section 22' of a short tubing string 22. Thecirculating device is located between a lower well packer 23 and anupper well packer 24 which seal between the tubing strings and the innerwall surface of a Well casing 25. The circulating device opens andcloses the ports 21a in the long tubing string for circulation betweenthe tubing string and the casing annulus. A well head 30 is supported atthe surface providing a closure over the upper end of the casing and hassuitable apertures through which the tubing strings extend into thewell. A conduit 31 having a valve 32 is connected to the short tubingstring above the well head and similarly, a conduit 33 having a valve 34is connected to the long tubing string 21. Another conduit 35 having avalve 40 is connected into the well head to the casing annulus 41defined within the well casing 25 around the tubing strings 21 and 22.

The circulating device 20 is lowered into a well with the ports 21aclosed either at the time of or subsequent to the setting of the lowerpacker 23. After expanding the lower packer, the long tubing string isplugged at its lower end below the circulating device, as discussed indetail hereinafter, a pressure differential is applied between theinterior of the long tubing string and the casing annulus opening thecirculating device, and the desired circulation procedure is carried outwithin the well bore above the expanded lower packer. The upper packeris then expanded and the circulating device is closed by movement of thelower section 22' of the short tubing string relative to the long tubingstring 21.

The circulating device 20, shown in detail in FIGURES 4, 5, and 6,includes telescopically coupled lower and upper sleeve valves 50 and 51which are slidable both on the flow conductor 21 and relative to eachother. The sleeve valves serve as a closure over ports 21a of the longtubing string, as described in detail below. The sleeve valve 50 has alower thick walled portion 50a which is initially disposed over theports 21a and supports an internal ring seal 53 to seal between thesleeve valve and the outer surface of the tubing string section 21 belowthe ports. The bore of the sleeve valve 50 is enlarged providing anintermediate portion 50b of reduced wall thickness and is furtherenlarged along an upper end portion 50c of still further reduced wallthickness. The upper sleeve valve 51 has a lower end portion 51a ofreduced wall thickness so that the portion 51a may be telescoped intothe lower sleeve valve above its lower end portion I 50a, as best seenin FIGURE 5. The upper sleeve valve has an external ring seal 54 whichseals between the intermediate portion 50b of the lower sleeve valve andthe portion 511: of the upper sleeve valve.

Due to the sliding fit between the lower sleeve valve and both thetubing string section 21 and the reduced lower end portion 51a of theupper sleeve valve pressure within the tubing string is communicatedfrom the ports 21a downwardly within the lower sleeve valve portion 50aalong the tubing string outer surface to the line of sealing engagementbetween the ring seal 53 and the tubing string surface. Similarly, thepressure is communicated from the ports upwardly within the intermediateportion 50b of the lower sleeve valve along the upper sleeve valveportion 51a to the line of sealing engagement between the ring seal 54and the internal surface of the lower sleeve valve. Thus, the pressurewithin the tubing string acts on upwardly facing surface portions of thelower sleeve valve over an effective annular area thereof between thelines of sealing engagement of the ring seals 53 and 54 with the tubingstring and lower sleeve valve, respectively, biasing the lower sleevevalve downwardly toward an open position with respect to the ports 21a.Similarly, of course, the pressure exterior of the tubing string exertsan upward force on the lower sleeve since the area of the downwardlyfacing surfaces of the lower sleeve valve exposed to the externalpressure is greater than the area of its upwardly facing surfacesexposed to the external pressure and biases the lower sleeve valveupwardly. The lower sleeve valve is releasably secured to the uppersleeve valve by a pair of shear pins 55. At the initial closed positionof the circulating device illustrated in FIGURES 4 and 5 fluid pressuretransmission upwardly between the tubing string and the sleeve valvesfrom the ports 21a is limited by a pair of internal lower ring seals 60supported within the lower end portion of the upper sleeve valve.

A pair of upper internal ring seals 61 are disposed within the sleevevalve 51 spaced from its ring seals 60 so that when the upper sleevevalve is moved downwardly to close the ports 210, the ring seals 60 arethen positioned below the ports and the ring seals 61 above the ports.

The upper sleeve valve 51 has a reduced upper portion 51b threaded intoa dual collar type operator member 62 slidably disposed on the longtubing section 21' and secured to the short tubing section 22'. Thecollar 62 is locked on the short tubing string section 22' by upper andlower lock rings 63 on a threaded portion 22a of the tubing stringsection. Longitudinal movement of the short tubing string section 22'relative to the long tubing string moves the operator member on the longtu'bing string shifting the sleeve valve 51 along the tubing string.

The sections of the long and short tubing strings on which thecirculating device is supported are each relatively short special tubingsections included in strings of standard tubing making up both the longand short tubing strings. The long tubing string section 21' is providedwith the ports 21a and is coupled into the long tubing string below theupper packer by the coupling collars 21" which are in turn connectedwith conventional tubing sections 21" which make up the remainder of thelong tubing string both below and above the upper packer. Similarly, theshort tubing string section 22 is a special section adapted to besecured through the operator member 62 and connected with conventionaltubing sections 22" which make up the remainder of the short tubingstring above and below the upper packer. The short tubing section 22 hasan enlarged upper box section 22b which is threaded on the lower endofthe tubing section 22" above the circulating device. The tubingsection 22 is also provided at its lower end with a coupling 220 intowhich is threaded a male coupling 22d from which additional tubingsections may be supported, if desired.

The lower end of the short tubing string 22 is provided with a ringshaped ball seat 70 secured by shear pins 71 within the tubing stringwhich is engageable by a plugging ball 72, FIGURE 3, to close the lowerend of the short tubing string for setting the upper packer and closingthe circulating device 20. Similarly, the long tubing strin is providedwith a ring shaped ball seat 74 below the circulating device securedwithin the tubing string by shear pins 75 which is engageable by a ballfor closing the long tubing string.

The lower packer 23 is any suitable, single, standard well packer whichseals between the long tubing string 21 and the well casing 25 below thecirculating device. Several packers suitable for the purpose are theOtis Perma-Trieve Production Packers illustrated at pages 3790-3791 ofthe 1966-67 edition, Composite Catalogue of Oil Field Services andEquipment, published by World Oil, Houston, Tex. Similarly, the upperpacker 24 may be any suitable packer for sealing around at least twotubing strings with one of the tubing strings being movable relative tothe other to effect the desired operation of the circulating device 20.For example, a suitable packer, illustrated diagrammatically in FIGURES2A and 3A, is shown at pages 3810-3811, Composite Catalogue of Oil FieldServices and Equipment, supra, and also is shown in United States PatentNo. 3,288,218, issued to C. R. Young, Nov. 29, 1966.

Referring to FIGURES 2A and 3A, the upper packer 24 includes a headhaving a pair of passages 91 and 92 which constitute upper end portionsof passages 92 and 93, respectively, through the packer. A long mandrel94 is rigidly secured to the head in communication with the passage 91and a short mandrel 95 is movably secured to the head in communicationwith the second passage 92. The bores or longitudinal passages of themandrels 94 and 95 constitute lower portions of the passages 92 and 93,respectively. The lower end of the portion of the long tubing string 21above the packer is receivable in the passage 91 and the lower end ofthe portion of the short tubing string above the packer is receivable inthe passage 92 of the packer head. The

packer also includes a hold-down body secured to the short mandrel 95and having a pair of parallel passages 101 and 102, the long mandrel 94extending through the passage 101 while a dependent tubular section 90aof the head 90 is telescoped into the upper end of the passage 102. Aplurality of resilient packing elements 103 disposed about the mandrelsare compressed and expanded laterally to seal between the mandrels andthe well casing by a downward movement of the hold-down body 100 on thelong mandrel. The packing elements are disposed between the downwardlyfacing shoulder or surface 104 of the hold-down body and an upwardlyfacing shoulder 105 of an expander 110 disposed around both the long andshort mandrels. The packing elements are expanded when downward movementof the expander on the long mandrel which extends through the expanderis arrested after the expander has moved a plurality of locking slips111 outwardly to expanded positions at which the locking slips engagethe well casing. The locking slips 111 are mounted on a slip carrier 112releasably held against downward movement on the mandrels 94 and 95disposed through parallel passages of the slip carrier which is heldagainst downward movement by a latch or holding assembly 113. The latchassembly includes a cylinder 114 releasably secured to the long mandrelby a shear pin 115. The mandrels 94 and 95 extend through parallelpassages of the cylinder to its downwardly opening bore 120. A piston121 is disposed in the cylinder on the mandrels and with the cylinderdefines a chamber 122 into which fluid pressure from the short mandrelis communicated by lateral ports 123 therein. The piston is held againstdownward movement relative to the dependent section 22" by engagementwith a stop shoulder 124 of an enlarged upper end portion of a dependentsection 22" of the short tubing string 22 secured to the short mandrel95 and extending downwardly from the packer. The cylinder has a latchassembly 124a engageable with the short mandrel which permits downwardmovement of the short mandrel relative to the cylinder but prevents itsupward movement thereto. The holddown body 100 is releasably held in theupper position on the long mandrel illustrated in FIGURE 2A by a shearpin 125 and is provided with hold-down buttons 130 which are movableoutwardly to engage the well casing and prevent upward movement of thehold-down body in the casing by fluid pressure from below the resilientpacking elements communicated to the hold-down buttons by fluid passageswhich extend through the hold-down body, the packing elements, and theexpander, when the pressure below the expanded packing elements exceedsthe pressure there-above by a predetermined value. Further, the downwardmovement of the short mandrel 95 during the setting of the packer lowersthe short tubing string sections below the packer supported from theshort mandrel shifting the sleeve valve 51 to its closed position,FIGURES 3 and 4. Further structural details of the upper packer 24 areillustrated and described in US. Patent No. 3,288,218, supra.

In use, the single string lower packer 23 is set in the casing 25between the lower perforations 26 and upper perforations 27 in anysuitable conventional manner. The circulating device 20 along with thelower sections of the long and short tubing strings associated with itbelow the upper packer are connected with the mandrels 94 and 95 of theupper packer in the relationship illustrated in FIGURES 2A and 4 withthe lower sleeve 50 locked by shear pins 55 to the upper sleeve valve.The lower sleeve 50 is over the ports 21a closing the circulatingdevice. The upper packer is supported on the sections of the long tubingstring 21 above the packer, the lower end portion of the lowermost ofsuch sections being releasably secured into the first passageway 91 ofthe head 90. The upper packer with the circulating device supportedtherefrom is lowered through the well casing until the lower end portionof the long string 21 below the circulating device is inserted into andlanded in the lower packer 23. The upper portion of the short tubingstring 22 is then lowered into the well bore until its lower end portionis seated in and releasably secured in the flow passage 92. The wellhead is installed on the casing and the flow conductors 31, 33, and 35are connected to the flow conductors and the well head.

The lower ends of the long and short tubing strings are open while theyare being lowered through the well casing to their final positionswithin the well bore so that drilling fluid in the well bore rises inthe tubing strings as they move downwardly. After the well head is setand the necessary surface connections are made as discussed above, thevalve 40 in the conduit 35 to the casing annulus is closed while thevalves 32 and 34 in the conduits leading to the tubing strings areopened so that the desired circulation may be effected through thetubing strings for circulating drilling fluid from the tubing stringsand easing annulus praparatory to producing the wells. A plugging ball82 having a density exceeding that of the well liquids is introducedinto the long tubing string 21. The ball sinks downward in the drillingfluid filled tubing string coming to rest at the lower end of the tubingstring on the ball seat thereby plugging the tubing string andpreventing fluid communication between its interior and the casingannulus below the lower packer 23. The ball seat 80 is shear pinnedwithin the lower end of the long tubing string with pins of greatershear strength than the shear pin 55 of the circulating device and theplugging ball 82 is of a material which prevents its extrusion throughthe ball seat so that the long tubing string remains plugged throughoutand subsequent to the opening of the circulating device. Fluid,generally water, is pumped then through the conduit 33 into the longtubing string building up the pressure within the tubing string since itis plugged at its lower end by the ball until the pressure differentialbetween the interior of the'tubing string at its ports 21a and thecasing annulus around the tubing string at the ports is sufiicient toshear the pins 55 and force the lower sleeve valve 50 downwardly to itsopen position illustrated in FIGURE 2. The pressure within the tubingstring is transmitted through the ports 21a along the tubing string andthe upper sleeve valve 51 within the lower sleeve valve to the ringseals 53, 54 and 60 biasing the lower sleeve valve downwardly relativeto the tubing string and the upper sleeve valve by a force resultingfrom the pressure acting over an effective upwardly facing annular areadefined between the line of sealing engagement of the ring seal 53 withthe outer surface of the tubing string on the inside and the line ofsealing engagement between the outer ring seal 54 with the insidesurface of the intermediate portion 50b of the lower sleeve valve. Thepressure around the tubing string acts upwardly on the lower sleevevalve over an effective annular area between the ring seals 53 and 54.The upper sleeve valve 51 is held against upward movement by theoperator member 62 which is secured at a fixed position on the tubingstring by the lower section 22' of the short tubing string 22. When thepressure differential across the lower sleeve valve exceeds apredetermined value, the pins 55 are sheared releasing the lower sleevevalve for downward movement on the tubing string to a position spacedbelow the upper sleeve valve. The lower sleeve valve is forceddownwardly away from the upper sleeve valve opening the ports 21a, asillustrated in FIGURE 2. During its downward movement, shortly afterseverance of the shear pins 55, the inner surface of the intermediateportion 50b of the lower sleeve valve passes below the ring seal 54 andthe fluid pressure within the tubing string is transmitted outwardlybetween the lower sleeve valve and the outer surface of the lower endportion of the upper sleeve valve. Since the space between the upper andlower sleeve valves at the time the ring seal 54 ceases to be effectiveis still relatively small, the pressure drop in the fluid flowing in theannular space between the sleeve valve portions 50b and 51a issufficient to continue to apply a downward force on the lower sleevevalve to move it on to a fully open position. The distance the lowersleeve valve moves downward on the tubing string depends, of course,upon the conditions under which the valve is opened, including thepressure differential across the valve at the time the pins 55 aresheared. If the pressure differential is particularly high when the pinsare sheared, the sleeve valve will generally move rapidly downwardly tofully uncover the ports 21a establishing communication between theinterior of the tubing string and its exterior within the casing annulus41. During the opening of the circulating device, the upper packerremains at the position shown in FIGURE 2A.

As soon as the circulating device is opened, as shown in FIGURE 2, thefluid within the long tubing string is pumped outwardly through theports 21a into the casing annulus. Since the valve 40 in the conduit 35leading to the casing annulus is closed while the valve 32 in theconduit 31 from the short tubing string is open and the lower end of theshort tubing string below the upper packer is open, circulation isestablished into the short tubing string so that fluid within the casingannulus flows upwardly in the short tubing string and from the wellthrough the conduit 31 as fluid is forced into the long tubing string atthe surface. The circulation through the long tubing string, the casingannulus, and the short tubing string continues until the drilling fluidwithin the tubing strings has been circulated out of the well bore tothe surface leaving the tubing strings substantially filled with thefluid being used to circulate, which, as stated previously, may comprisewater. Some of such drilling fluid between the open lower end of theshort tubing string and the ports may also be removed in this manner.

After the desired circulation procedure has been completed, thecirculating device is closed and the upper packer is set so that thewell may be produced. To close the circulating device and set the upperpacker the pressure is raised in the short tubing string after theplugging ball 73 is inserted at the surface into the short tubing stringand is pumped or allowed to move by gravity downwardly to a seatedposition, FIGURE 3, on the ball seat 70 at the lower end of the tubingstring below the upper packer 24. The fluid pressure in the short tubingstring is increased as by pumping into it at the surface through theconduit 31. The increased fluid pressure is communicated through thelateral ports 123 of the short mandrel into the chamber 122 of the upperpacker between the cylinder and piston of its latch assembly causing thepiston to exert a downward force on the short mandrel. Upward movementof the cylinder is prevented by the shear screw 115 which is of greaterstrength than the shear screw 125 which secures the hold-down body tothe long mandrel 94. The screw 125 shears as the pressure in the chamberis increased and the hold-down body 90 is released for downward movementrelative to the head and the long mandrel. The force exerted by thepiston on the shoulder surface 124 of the short mandrel moves thehold-down body downwardly relative to the head and the long mandrel. Theexpander 110 expands the slips 111 until their teeth engage the wellcasing 25 and further downward movement of the expander is arrestedwhereupon continued downward movement of the hold-down body compressesand expands the resilient packer elements 103 into sealing engagementwith the well casing closing the passage between the well casing and thelong and short mandrels. When the packing elements are at their expandedsealing position, pressure in the well casing below the'packing elementsis communicated to the internal surfaces of the hold-down buttons 130and when such pressure is greater by a predetermined value than thepressure above the packing elements the hold-down buttons are movedoutwardly to cause their upwardly facing teeth to engage the well casingand limit the hold-down body against upward movement. The greater thepressure below the packing elements the greater the force with which thehold-down buttons are held in engagement with the well casing.

When the piston 121 forces the short mandrel 95 downwardly relative tothe long mandrel to expand the packing elements and lock the packer inthe well casing, the downward movement of the short mandrel lowers theshort tubing string section 22' below the packer relative to the longmandrel 94 which supports the lower end portion of the long tubingstring below the packer. The operator member 62 is forced downwardly onthe long tubing string moving the upper sleeve valve 51 downwardly onthe tubing string. The upper sleeve valve slides over and closes theports 21a with the lower internal ring seals 60 of the sleeve valvebeing located below the ports at the lower end of the downward stroke ofthe short tubing string portion and the operator memher. The lower endportion 51a of the upper sleeve valve 51 may telescope into the lowersleeve valve 50, FIGURE 3, though such relationship with the lowersleeve valve is not essential to closure of the tubing string ports 21asince flow through the ports is prevented by the presence of the ringseals 60 and 61 Within the upper sleeve valve above and below,respectively, the ports. Complete insertion of the lower end portion ofthe upper sleeve valve into the lower sleeve valve is, of course,dependent on the extent to which the lower sleeve valve was forceddownwardly by the fluid pressure differential across it during theopening procedure. If the lower sleeve valve was forced downwardly agreater distance than the stroke of the operator member, obviously theupper sleeve valve will not be fully reinserted into the lower sleevevalve upon closure of the circulating device. The status of the lowersleeve valve is, however, of no consequence since reclosure of thetubing string ports fully effected by the upper sleeve valve.

With the upper sleeve valve 51 fully closed fluid communication isprevented between the casing annulus between the packers and the longtubing string. The operator member 62 is held down by the short tubingstring to prevent accidental opening of the upper sleeve valve. Sincethe lines of sealing engagement of the upper and lower seal rings 61 and60, respectively, with the outer surface of the long tubing string areof the same diameter and since the entire outer surface portions of theupper sleeve valve above and below its internal seal rings are allexposed to pressure within the casing annulus, the sleeve valve is notmovable responsive to either the pressure within the long tubing stringor within the easing annulus between the packers. Therefore, anypressure differential which may exist between the casing annulus and theinside of the long tubingstring at the circulating device has no effectupon the closed upper valve sleeve and thus there is no tendency forpressure to reopen the valve.

The plugging ball 73 at the lower end of the short tubing string and theball 82 at the lower end of the long tubing string are removable fromtheir respective ball seats by either of two procedures, Preferably, thesurface flow control devices including. the valves 32 and 34 areadjusted, after pumping into the conduits 31 and 33 is terminated, toallow the well to begin to produce through the tubing strings withupward flow of fluids entering the well through the ports 27 beingeffected through the short tubing string from between the packers andupward flow from below the lower packer entering the well through theports 26 and flowing upwardly in the long tubing string. The pluggingballs in the tubing strings are carried upwardly to the surface by thefluids being produced through the tubing strings. The halls are removedat the surface from each of the tubing strings. Alternatively, the balls73 and 82 may be displaced outwardly from the lower ends of the tubingstrings by increasing the pressure sufficiently within the tubingstrings to shear the pins holding each of the ball seat rings within itsrespective tubing string. For example, the pressure differential acrossthe ball seat and ball 82 is raised to a value sufiicient to apply adownward force to the seat and ball of a value sufiicient to shear thepins 81. Similarly, the pins 71 in the short string are shearedreleasing its seat 70 and ball 73. If this latter procedure is followedfor removing the plugging balls, both the ball and the ball seat in eachof the tubing strings is displaced from the tubing string downwardlyinto the well bore.

After the plugging balls are removed from the tubing strings, the wellis produced through either or both tubing strings with communicationthrough the ports 21a being prevented by the closed circulating device.The circulating device is not adapted to be reopened within the wellbore and thus requires removal from the well bore with the upper packerand resetting if repetition of its opening and closing function isdesired. The upper packer is removed in accordance with the proceduresdiscussed in detail in U.S. Patent No. 3,288,218 and since such removalis unrelated to the structure and function of the circulating device 20it is not discussed in detail herein.

It will now be seen that a new and improved well tool for circulationbetween the interior and exterior of a flow conductor in a well bore hasbeen illustrated and described.

It will be further seen that the circulating device is employed forcirculating fluids out of the well bore during the setting of the wellpackers.

It will also be seen that the circulating device includes a slidingsleeve valve for controlling fluid communication between the interiorand exterior of a flow conductor disposed in a well bore.

It will be further seen that the sliding sleeve valve is opened by afluid pressure differential at the valve between the interior andexterior of the flow conductor within the Well bore.

It will be further seen that the sleeve is closed by a mechanical forceapplied from a second flow conductor disposed within the well bore andmovable relative to the flow conductor on which the sleeve is supported.

It will be further seen that the sleeve valve includes first and secondsleeve members telescopically related and slidable along the flowconductor, the sleeve valve members initially closing a port in the flowconductor and one of the sleeve valve members being movable by a fluidpressure differential between the interior and exterior of the conductorto an open position and the second sleeve valve member being movablethereafter to a closed position to close the port by a mechanical force,the second sleeve valve member being held in such closed position by anoperator member employed to apply the closing mechanical force to thesleeve valve.

It will be further seen that a well system has been described andillustrated including a first long flow conductor, a second short flowconductor, an upper packer for sealing between the flow conductors and awell bore wall, a lower packer for sealing between the long flowconductor below the lower end of the short flow conductor, the shortconductor having a portion below the upper packer movable relative tothe long flow conductor, and valve means disposed about the long flowconductor movable to an open position by a fluid pressure diflerentialbetween the interior of the long flow conductor and the well bore andreturnable to a closed position by an operator member coupling the valveand the movable short flow conductor portion below the upper packer.

It will be further seen that the telescopically related sleeve valvemembers include a lower member provided with an inner ring seal sealingbetween the valve member and the tubing string and an outer ring sealsealing between the valve member and the second sleeve valve memberdefining an annular area on the first sleeve valve member which when inclosed position over the tubing string port is exposed on the inside tothe pressure within the tubing string and on the outside to the pressurewithin the well bore around the tubing string whereby a greater pressurewithin the tubing string biases the sleeve valve member toward an openposition relative to the tubing string port.

Another form of circulating device embodying the invention isillustrated in FIGURE 7 at its initial closed position. The circulatingdevice 140 includes a sleeve valve 141 slidably supported on a longtubing string section 211; which is supported from the long mandrel 94of the upper packer 24 and is threaded at its lower end into a coupling210 connected with a coupling collar 21" which in turn is connected withanother long tubing string portion, not shown, which extends downwardlyinto the lower packer 23. The tubing string section 21b has ports 21dfor communication between the interior of the long tubing string and thewell bore between the upper and lower packers and which are open andclosed by the sleeve valve 141.

The sleeve valve 141 is slidably disposed on the long tubing stringsection 21b for longitudinal movement thereon to open and close theports 21d. The sleeve valve is initially releasably secured at a closedposition by a shear pin 142 extending through the sleeve valve into ashallow blind recess 143 in the outer surface of the tubing section 21b.The sleeve valve has a head section 144 and a lower skirt portion 145.The valve has an upper bore portion a extending through its head portion144 of a diameter to provide a sliding relationship on the tubingsection 21b and a coaxial lower enlarged bore portion 15% extendingthrough its skirt portion 145. A pair of seal rings 151 are disposedwithin the head section of the sleeve valve to seal between the valveand the outer surface of the tubing section 21b. \An annular flexibleseal 152 is disposed around the tubing string portion 21b below theports 21d between a pair of retainer rings 153. The downward movement ofthe seal 152 and its retainer rings is limited by the upper end surface154 of the coupling 21c and their upward movement is limited by a splitretainer ring 155 disposed in an external annular recess of the tubingsection 21b below its ports 21d. The seal 152 seals between the innersurface of the skirt portion 145 of the sleeve valve and the long tubingstring section below its ports 21d so that when the sleeve valve is atits closed position fluid may not flow downwardly from the ports 21d dueto the presence of the seal 152 and similarly may not flow upwardlybetween the sleeve valve and the tubing string section because of theseal rings 151.

The sleeve valve 141 is exposed to pressure transmitted from within thelong tubing string through its ports 21d over surface portions having aneffective net downwardly facing annular area defined between the line ofsealing engagement of the annular seal 152 with the inner wall surfaceof the skirt portion 145 of the sleeve valve and the line of sealingengagement between the ring seals 151 with the outer wall surface of thetubing string section 21b. The pressure within the tubing string actingover this annular area of the sleeve valve biases the valve upwardlytoward open position on the tubing string section. The sleeve valve issimilarly exposed to pressure within the well bore between the packersaround the tubing string section so that the casing annulus pressuretends to bias the sleeve valve downwardly toward its closed position.

An external annular flange 161 is formed on the tubing coupling 21cproviding an upwardly facing annular stop shoulder 161a located to limitthe downward movement of the sleeve valve 141 during its closure to aposition at which the lowermost of the ring seals 151 is located abovethe ports 21d so that when the sleeve valve is closed its internal ringseals are above the ports 21d. An operator member collar 162 is disposedaround the long tubing string 21b above the sleeve valve 141 and securedto the short tubing string section 220. The sleeve valve is closed bymoving the operator member down by the short tubing string section toengage the upper end surface 144a of the sleeve valve.

A well system in which the alternate form 140 of the circulating deviceis used is identical to the system disclosed in FIGURES 1-3 and isoperated in exactly the same manner as described above. When the lowerpacker has been set, the upper packer along with the tubing stringspositioned in the well and the well head connected, a plugging ball '82is inserted into the long tubing string and pressure is applied withinit by pumping fluid into it at the well head. A pressure differential isdeveloped across the sleeve valve 141 between the interior of the tubingstring section 21b and the casing annulus between the packers. When thepressure in the long tubing string is raised to a predetermined valveabove the casing annulus pressure the pin 142 is sheared releasing thesleeve valve for movement on the tubing string section. The force of thepressure differential applied to the effective downwardly facing surfaceportions defined between the ring seals 151 and the annular seal 152forces the sleeve valve upwardly on the tubing section to a position atwhich the lower end of the skirt portion 145 of the sleeve valvesufficiently clears and is spaced above the seal 152 to allow thedesired fluid flow from within the long tubing string outwardly into thecasing annulus. Generally, the pressure differential required to shearthe pin 142 is sufficient to force the sleeve valve upwardly to thedesired open position on the tubing string section to uncover the ports21d enough to allow the desired circulation between the tubing and thecasing annulus. The exact position of the sleeve valve at the upper endof its stroke on the tubing string will obviously depend upon thepressure differential applied across the valve for moving it to its openposition.

These procedures described in connection with the circulating device 20are followed with the circulating device 140 through and including thesetting of the upper packer 24 by increasing the pressure within theshort tubing string as previously discussed. The downward movement ofthe short mandrel of the upper packer during its setting forces theoperator member 162 downwardly on the long tubing string section 21d sothat the operator member engages the upper end surface 144a of thesleeve valve 141 forcing it back downwardly on the tubing string sectionto its closed position over the ports 21d. Generally the sleeve valve isreturned substantially to the position shown in FIGURE 7. As soon as theinternal surface of the skirt portion 145 of the sleeve valve moves overthe annular seal 152 the ports 21d are effectively again closed with theoperator member 162 bearing against the upper end of the sleeve valveholding it at its closed position.

In contrast with the circulating device 20, the sleeve valve 141 doeshave a tendency to move to the open position at any time the pressurewithin the long tubing string exceeds the pressure within the casingannulus between the packers and thus it is essential that the operatormember 162 remain engaged with the upper end of the sleeve valve to holdit at the closed position. Obviously, any pressure within the casingannulus exceeding the pressure within the long tubing string between thepackers acts over the effective upwardly facing annular surface portionsof the sleeve valve defined by the upper ring seals 151 and the annularseal 152 tending to force the sleeve valve to a more tightly closedposition.

After the sleeve valve 141 is returned to and held at its closedposition by the operator member 162, the well is placed in production inthe same manner as described above.

It will now be seen that a further alternate form of a a circulatingdevice embodying the invention has been described and illustrated,including a sleeve valve slidably supported on a long flow conductor ofa well system for movement between positions opening and closing alateral port in the flow conductor and having inner and outer seal meansfor sealing between the flow conductor and the sleeve valve above andbelow the port and defining an annular area exposed to the pressurewithin the flow conductor biasing the valve toward an open position andan effective annular area of outer surface portions exposed to thepressure within the casing annulus biasing the valve toward a closedposition, the valve being releasably secured at a closed positioninitially by shearable means and being opened by a pressure differentialbetween the interior flow conductor and the pressure around its exteriorand closed by an operator member on the long flow conductor above thevalve and coupled with and moved by a short flow conductor disposedwithin the well adjacent to the long flow conductor.

The circulating devices 20 and 141, as illustrated, are generally usedin well systems where the upper and lower packers are reasonably closetogether within the well bore, spaced apart, for example, no greaterthan about 200 feet. An alternate form of the circulating device A isillustrated in FIGURE 8 for use in systems where operating requirementsnecessitate a substantially greater distance between the upper, andlower packers and the long string circulating ports are located near thelower packer with the open end of the short tubing string section beingnear the upper packer. The circulating device 140A is identical in allrespects to the device 140 except that it includes an extension sleeveslidably disposed around the long string tubing section 21b supportedfrom the operator member 162 for applying a downward force from theoperator member to the sleeve valve 141 to close the sleeve valve. Theextension sleeve 165 spans the substantial distance between the operatormember and the sleeve valve when the upper and lower packers are spacedapart a larger distance than practical for use of the previouslydescribed circulating devices. Of course, the extension sleeve 165 ofthe operator member is lowered as the short mandrel of the upper packeris lowered during the setting of the upper packer to effect closing ofthe sleeve valve 141. The circulating device 140A is operated exactly asthe previously discussed circulating devices.

It will now be seen that a further alternate form of circulating devicefor use in a well bore between packers has been described andillustrated including an extension sleeve between the operator member ofthe circulating device extending downwardly to its sliding sleeve valvefor closing the valve when well requirements necessitate a substantialdistance between the upper and lower pockers.

The foregoing description of the invention is explanatory only, andchanges in the details of the construction illustrated may be made bythose skilled in the art, within the scope of the appended claims,without departing from the spirit of the invention.

What is claimed and desired to be secured by Letters Patent is:

1. A well tool comprising: a flow conductor adapted to be disposed in awell bore, said flow conductor having a port for fluid communicationbetween the interior and exterior of said flow conductor; tubular valvemeans slidable longitudinally on said flow conductor for closing andopening said port; fluid pressure means for operating said valve meansto open said port by fluid pressure from within said flow conductor inexcess of the pressure exteriorly thereof; and means slidablelongitudinally on said flow conductor for operating said valve means toclose said port.

2. A well tool as defined in claim 1 wherein said means for closing saidport is operable responsive to a mechanical force.

3. A well tool as defined in claim 2 wherein a second flow conductor isadapted to be disposed in said well bore and said means for closing saidport is connected with and responsive to movement of said second flowconductor for movement relative to said first mentioned flow conductorto close said port.

4. A well tool as defined in claim 1 wherein said tubular valve meanscomprises sleeve means slidable on said flow conductor; and said meansfor opening and closing said port comprises an operator member slidableon said flow conductor and operable by another flow conductor movablelongitudinally relative to said first mentioned flow conductor.

5. A well tool as defined in claim 4, wherein said sleeve meanscomprises a sleeve movable from a first closed position over said portto a second open position permitting communication between the interiorand exterior of said fiow conductor through said port and back to saidfirst closed position.

6. A well tool as defined in claim 1, wherein said means for operatingsaid valve means to close said port includes an operator member movableon said flow conductor for engaging and moving said sleeve from saidopen position back to said closed position.

7. A well tool as defined in claim 6 wherein said operator member iscoupled to and movable by another flow conductor movable relative tosaid first mentioned flow conductor.

8. A well tool comprising: a flow conductor adapted to be disposed in awell bore, said flow conductor having a port for fluid communicationbetween the interior and exterior of said flow conductor; sleeve meansslidable on said flow conductor for closing and opening said port, saidsleeve means including: telescopically disposed first and second sleevevalves, said first sleeve valve being movable from said positioncovering said port to said position uncovering said port responsive to apressure differential across said sleeve valve between the interior andexterior of said flow conductor, said second sleeve valve being movableto a position covering said port responsive to a mechanical forceapplied thereto.

9. A well tool as defined in claim 8 including an operator membermovable on said flow conductor for engaging and moving said secondsleeve over said port.

10-. A well tool as defined in claim 9 wherein said operator member iscoupled to another flow conductor disposed in said well bore and adaptedto move longitudinally relative to said first mentioned flow conductor.

11. A well tool for circulating fluid between the interior and exteriorof a fiow conductor comprising: a flow conductor adapted to be disposedin a Well bore, said flow conductor having a port spaced from the endthereof for communication between the interior and exterior of said flowconductor; a valve on said flow conductor for covering and uncoveringsaid port, said valre including a slidable sleeve on said flowconductor; first inner seal means for sealing between said sleeve andsaid flow conductor; second outer seal means for sealing between saidsleeve and said flow conductor; said first and second seal meansdefining an annular area of said sleeve exposed on one side to pressurewithin said flow conductor and on the opposite side to pressure outsideof said flow conductor, said sleeve being movable to a positionuncovering said port responsive to a pressure differential between theinterior and exterior of said flow conductor from within said flowconductor greater than the pressure on the exterior of said sleeveacting across said annular area of said sleeve; and mechanical meansmovable longitudinally of said conductor to engage said sleeve foractuating said valve to cover said port in said flow conductor.

12. A well tool as defined in claim 11 including means for releasablylocking said sleeve on said conductor at a position covering said port,an operator member slidable along said flow conductor for moving saidsleeve from said position uncovering said port back to said positioncovering said port, said operator member being coupled with another flowconductor disposed in said well bore and movable relative to said firstmentioned flow conductor, and stop means on said first mentioned flowconductor to limit the return movement of said sleeve to said positioncovering said port.

13. A well tool as defined in claim 12 including means for temporarilyclosing said first mentioned flow conductor below said port for applyingsaid pressure ditferential across said annular area for moving saidslidable sleeve to said position uncovering said port.

14. The well tool of claim 13 in combination with first packing means onsaid first mentioned flow conductor below said port in said firstmentioned flow conductor for sealing between said conductor and a wellbore Wall and second packing means on said first and second mentionedfiow conductors above said port in said first mentioned flow conductorfor sealing between said flow conductor and a wall of a well bore, saidsecond packing means being adapted for movement of said second mentionedflow conductor relative to said first mentioned flow conductor forreturning said sleeve to said position cover in g said port.

15. A well tool for circulating fluid between a well bore and a flowconductor disposed therein comprising: a first flow conductor adapted tobe disposed within a well bore, said first flow conductor having a portspaced from the lower end thereof; a first sleeve valve movablysupported on said first flow conductor for closing said port at a firstposition and for opening said port at a second position; a second sleevevalve movably supported on said first flow conductor telescopicallyrelated with said first sleeve valve for movement to a position closingsaid port after said first sleeve valve is moved to said positionopening said port; inner seal means between said first sleeve valve andsaid first flow conductor; outer seal means between said first sleevevalve and said second sleeve valve; said inner and outer seal meansdefining an annular area of said first sleeve valve exposed on one sideto pressure within said first flow conductor and on the other side topressure exterior of said flow conductor whereby a greater pressurewithin said conductor biases said first sleeve valve toward saidposition opening said port; seal means between said first flow conductorand said second sleeve valve positioned on a side of said port oppositesaid inner seal means between said first sleeve valve and said firstflow conductor when said first sleeve valve is closing said port andspanning said port for sealing between said second sleeve valve and saidflow conductor on opposite sides of said port when said second sleevevalve is closing port; means between said first and second sleeve valvesfor holding said first sleeve valve over said port when the pressuredifierential across said annular area is below a predetermined value;and operator means for moving said second sleeve valve to a positionover and closing said port in said How conductor.

16. A well tool as defined in claim 15 including a second flow conductoradapted to be disposed in said well bore for movement relative to saidfirst fiow conductor and means coupling said operator means with saidsecond flow conductor whereby said second sleeve valve is moved alongsaid first flow conductor to said position closing said port in saidfirst flow conductor responsive to movement of said second fiowconductor relative to said first flow conductor.

17. A well tool as defined in claim 16 including means for temporarilyclosing said first flow conductor below said port therein for developinga pressure within said first flow conductor to apply said pressurediflerential across said annular area of said first sleeve valve formoving said valve to open said port in said first flow conductor.

18. The well tool of claim 17 in combination with a first well packer onsaid first fiow conductor below said port therein and a second wellpacker on said first and second flow conductors above said port in saidfirst flow conductor, said second well packer including means for movingsaid second fiow conductor relative to said first flow conductor formovement of said second sleeve valve to close said port.

19. Circulation means for a well installation having a first long fiowconductor and a second short flow conductor extending in parallelrelation in a well, an upper packer for sealing between said fiowconductors and the well and a second packer for sealing between saidlong flow conductor and the well below the bottom end of said short flowconductor and wherein said short flow conductor has a lower sectionextending below said upper packer movable downwardly relative to saidlong flow conductor during the setting of said first packer, saidcirculation means including: means providing a port in said long flowconductor between said packers for providing communication between saidlong fiow conductor and the well between said packers; valve meansdisposed about said first flow conductor and releasably secured theretoin closed position wherein said valve means closes said port, said valvemeans having means responsive to fiuid pressure in said long flowconductor, the fluid pressure in said flow conductor exerting a forcetending to move said valve means to open position, said valve meansbeing movable thereon from said closed position to an open position whenthe pressure differential between said long flow conductor and the wellbetween said packers exceeds a predetermined value to permit circulationthrough said port between the well and said long flow conductor beforesaid second flow conductor is set; and co-engageable means on said valvemeans and said section of said short flow conductor for moving saidvalve means from open to closed position on said first fiow conductorupon downward movement of said section of said second flow conductorduring the setting of said upper packer and for holding said valve meansthereafter in closed position.

20. The circulation means of claim 19, and means for closing said longfiow conductor below said port whereby the pressure in said long flowconductor may be increased to cause said valve means to move to openposition and permit circulation of fluids down one of said flowconductors into the well between said packer and upwardly from the wellbetween said packers through the other of said flow conductor.

21. A well tool comprising: housing means having means for connectingsaid housing means to a first flow conductor, said housing means havingan opening for receiving tubular conductor means; a tubular conductormeans longitudinally slidably disposed in said housing means opening andhaving means for connecting it to a second flow conductor; said tubularconductor means having port means providing communication between theinterior and exterior thereof; one of said tubular conductor means andsaid housing means being movable longitudinally relative to the otherfor shifting the relative position of said port means with respect tosaid housing means; and seal means spaced longitudinally with respect tosaid housing means disposed for sealing on longitudinally opposite sidesof said port means between said tubular conductor means and said housingmeans when said tubular conductor means is disposed longitudinally withrespect to said housing means in a first position with said port meanswithin said housing means whereby flow communication through said portmeans is closed ofi, said tubular conductor means and said housing meansbeing movable longitudinally relative to each other to a second positionin which said port means is disposed to permit flow communicationthrough said port means between the interior and exterior of saidtubular conductor means.

22. A well tool comprising: housing means having means for connectingsaid housing means to a first flow conductor, said housing means havingan opening spaced laterally from said means for connecting said housingmeans to said first flow conductor; a tubular conductor meanslongitudinally slidably disposed in said housing means opening andhaving means for connecting it to a second flow conductor; said tubularconductor means having port means providing communication between theinterior and exterior thereof; one of said tubular conductor means andsaid housing means being movable longitudinally relative to the otherfor shifting the relative position of said port means with respect tosaid housing means; and seal means spaced longitudinally with respect tosaid housing means disposed for sealing on longitudinally opposite sidesof said port means between said tubular conductor means and said housingmeans when said tubular conductor means is disposed longitudinally withrespect to said housing means in a first position with said port meanswithin said housing means whereby flow communication through said portmeans is closed ofi, said tubular conductor means and said housing meansbeing movable longitudinally relative to each other to a second positionin which said port means is disposed to permit fiow communicationthrough said port means between the interior and exterior of saidtubular conductor means.

23. A well tool comprising: a first flow conductor having port means forcommunication between the interior and exterior thereof; housing meanssupported on said first flow conductor; one of said first flow conductorand said housing means being movable relative to the other betweenrelative positions at which said port means is within said housing meansand said port means is disposed longitudinally from said housing means;said housing means having means for connecting a second flow conductorthereto; and longitudinally spaced seal means for sealing between saidhousing means and said first flow conductor, said seal means being onlongitudinally opposite sides of said port means when said port means iswithin said housing means for closing ofi? flow communication throughsaid port means.

References Cited UNITED STATES PATENTS 2,667,926 2/ 1954 Alexander166224 3,193,016 7/1965 Knox 166224 3,319,717 5/1967 Chenoweth 1662243,358,770 12/1967 Zandmer 166224 JAMES A. LEPPINK, Primary Examiner US.Cl. X.R.

